EP3299436A1 - Unterirdische halitabschwächung - Google Patents

Unterirdische halitabschwächung Download PDF

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Publication number
EP3299436A1
EP3299436A1 EP16190645.8A EP16190645A EP3299436A1 EP 3299436 A1 EP3299436 A1 EP 3299436A1 EP 16190645 A EP16190645 A EP 16190645A EP 3299436 A1 EP3299436 A1 EP 3299436A1
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Prior art keywords
mta
composition
well
halite
gas
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EP16190645.8A
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English (en)
French (fr)
Inventor
Cornelis Petrus Marcus Roelands
Johannes Franciscus Maria Velthuis
Barbara Antonietta LUBELLI
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Nederlandse Organisatie voor Toegepast Natuurwetenschappelijk Onderzoek TNO
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Nederlandse Organisatie voor Toegepast Natuurwetenschappelijk Onderzoek TNO
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Priority to EP16190645.8A priority Critical patent/EP3299436A1/de
Priority to EP17785042.7A priority patent/EP3516008A1/de
Priority to PCT/NL2017/050641 priority patent/WO2018056826A1/en
Priority to US16/336,375 priority patent/US20190218447A1/en
Publication of EP3299436A1 publication Critical patent/EP3299436A1/de
Withdrawn legal-status Critical Current

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    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
    • C09K8/528—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07F—ACYCLIC, CARBOCYCLIC OR HETEROCYCLIC COMPOUNDS CONTAINING ELEMENTS OTHER THAN CARBON, HYDROGEN, HALOGEN, OXYGEN, NITROGEN, SULFUR, SELENIUM OR TELLURIUM
    • C07F15/00—Compounds containing elements of Groups 8, 9, 10 or 18 of the Periodic Table
    • C07F15/02—Iron compounds
    • C07F15/025—Iron compounds without a metal-carbon linkage

Definitions

  • Embodiments relate to methods and uses of compositions for preventing, limiting, eliminating, and/or mitigating inorganic depositions in gas and oil wells and other subterranean systems.
  • halite deposition of crystalline NaCl
  • hydrocarbons in particular natural gas, but possibly also oil
  • halite deposits comprise predominantly NaCl (e.g. less than 10 wt.% other components).
  • Salt deposition is particularly severe in wells with high saline water such as brines. In such wells, water evaporates (e.g.
  • Halite deposition is often a problem in for example subsea fields, mature onshore wells, and unconventional shale reservoirs.
  • Halite salt deposition in gas wells is distinct from other types of scale formation (in particular, carbonate and sulfate) primarily because of the high solubility of NaCl and the accordingly higher precipitation masses with small degrees of oversaturation. Most standard scale inhibitors (e.g. for carbonate and sulfate scale) are ineffective against halite scaling, or would require unacceptable high concentrations.
  • a conventional mitigation strategy for halite deposition in gas wells is flushing with fresh water on a regular basis. However, in some instances, flushing would be necessary on a daily basis (or e.g. each few days). This reduces production time and is hence economically not attractive.
  • a brief summary of the challenge of preventing and mitigating NaCl salt deposition in low-pressure gas wells is given in the press release "Brenntag introduces new salt inhibitor for low-pressure gas wells" available at www.pressreleasefinder.com/pr/BTPR002/en.
  • the press release mentions that a salt inhibitor (T-3000E) is developed to prevent salt deposition. No information about the chemical identity or composition of the salt inhibitor is given.
  • the press release is not a technical document and does not provide an enabling disclosure.
  • the present invention aims to provide, in an aspect, methods for addressing (e.g. mitigating, preventing, and/or reducing) the problems caused by salt (halite) deposition in underground systems such as gas wells, in particular in low pressure gas wells.
  • Hexacyanoferrate is mentioned as halite inhibitor in Tore Tjomsland et al., "Halite Deposition - Thermodynamic Oversaturation and Chemical Qualification", Oil Field Chemistry Symposium, Geilo 13-16th March 2016 .
  • some commercial inhibitors were compared with hexacyanoferrate.
  • the document states that "the tests found limited chemical performance” for inhibitors from vendors (the chemical identities of the inhibitors are not given).
  • Use of hexacyanoferrate of as inhibitor is also mentioned in Bellarby, Well Completion Design (2009), page 396. Other uses of this compound are as anti-caking agent for particulate NaCl salt.
  • Anti-caking agents are used as additive for particulate salt, i.e. table salt. This is very different from mitigating halite deposition. Caking refers of the tendency of substantially dry, flowable, particulate salt (crystalline NaCl powder) to form large, agglomerated masses (lumps) upon exposure to moisture or humidity in the atmosphere. This so-called caking is due the formation of salt bridges between NaCl single crystals, in particular by repetitive solution and recrystallization of salt at the peripheral portions of individual salt particles by the formation of moisture layers when exposed to an atmosphere with fluctuating humidity. Anti-caking agents are often added to such particulate and flowable salt to prevent the formation of cakes. Such agents generally disrupt or prevent the formation of salt bridges. Hence, the caking of particulate salt is distinct from halite deposition in gas wells, if only because of the mechanisms and conditions at which these unwanted processes occur.
  • a consideration for underground halite deposition mitigation is that any compound introduced into subterranean systems, in particular into wells such as gas wells, should desirable not be of environmental or health concern (e.g. should not be toxic). Neither should any degradation product of such compound introduce environmental or health risks.
  • downstream processing of natural gas should be taken into account, in particular glycol dehydration as often used for water removal from natural gas.
  • Raw natural gas from gas wells contains significant amounts of water, such as up to saturation. This water could cause several problems downstream, such as freezing in piping and formation of hydrates. Liquid water may furthermore drop out of the natural gas upon cooling or pressure reduction. The liquid water will often be acidic and could cause corrosion.
  • glycol dehydration water is removed from the gas stream, most commonly by glycol dehydration.
  • a glycol absorber is used, together with a glycol stripper usually with a reboiler.
  • Glycol is thermally regenerated.
  • the reboiler temperature is for example about 200 °C or in the range of 200 to 300 °C.
  • Any gas well scale prevention method needs to be compatible with downstream processing, such as glycol dehydration.
  • Any halite deposition inhibitor used is desirably stable and effective under well conditions, e.g. at 100 °C to 200 °C, more preferably 150 to 200 °C.
  • the well pressure (e.g. in the near wellbore region) is for instance 100 - 200 bar, e.g. about 150 bar.
  • a background reference is EP 2597126 .
  • This document discloses a method of enhancing the adsorption of a salt inhibitor onto a wellbore region, the method comprising preconditioning the wellbore region, emplacing a salt inhibitor into the wellbore region and shutting in the well for a period of time sufficient to initiate adsorption of the salt inhibitor onto the wellbore region.
  • the salt inhibitor preferably comprises a Group 3-15 metal and an anion. Tartrate is mentioned as a possible anion.
  • a further reference is EP 0976911 describing inhibitors for inhibiting scale formation in a hydrocarbon production system such as an oil field.
  • a further reference is Chen et al. in SPE 121458 (a paper prepared for the 2009 SPE International Symposium on Oilfield Chemistry; Society of Petroleum Engineers) wherein it is mentioned that the inhibition of halite mineral scale formation in oil and gas production is notoriously difficult. The paper mentions that high concentrations of halite inhibitor always provide limited inhibition performance.
  • Paper SPE 169803-MS (a paper presented at SPE International Oilfield Scale Conference, 14-15 May 2014) of Ho et al mentioning a carboxylic acid halite scale inhibitor No further information about the chemical composition is given. In SPE 169803-MS four possible mechanisms are described to explain the performance of halite inhibitors: 1) inhibition of nucleation and growth, 2) crystal distortion, 3) dispersive effect (in particular for polymer inhibitors) and 4) film formation.
  • compositions for mitigating halite deposition in a gas well wherein the composition comprises ferri-meso-tartrate (Fe-mTa).
  • method of maintaining a hydrocarbon well comprising introducing a composition comprising Fe-mTa into the hydrocarbon well.
  • composition for mitigating halite deposition in a subterranean CO 2 storage site wherein the composition comprises Fe-mTa. Further aspects and embodiments are also provided.
  • the present invention provides, in an aspect, for the use of a composition comprising ferri-meso-tartrate (Fe-mTa) to mitigate halite deposition in hydrocarbon wells, in particular gas wells. More generally, the invention relates to use of compositions comprising Fe-mTa and/or similar compounds to mitigate halite deposition in subterranean systems, such as oil wells, gas wells, and subterranean storage sites in particular for fluids, especially CO 2 storage sites.
  • Fe-mTa ferri-meso-tartrate
  • mitigates includes but not restricted to one or more of preventing, inhibiting, reducing, limiting, eliminating and mitigating the effects of halite deposition.
  • the use is preferably for inhibiting clogging by halite deposition.
  • Halite deposition may occur for example in the near-wellbore region, optionally combined with depositions in other parts of a well.
  • the near-wellbore region comprises porous rocks close to (but not in) the well bore.
  • the near-wellbore region is generally next to the tubing. Water saturation as result of evaporation may occur in the near-wellbore region.
  • Preferred embodiments of the disclosed use and methods addresses halite deposition in the near-wellbore region, while optionally also addressing halite deposition in other well regions and/or scaling by other salts. Salt deposits may also form on well equipment, e.g. production tubing and chokes.
  • the described use may also provide advantages for mitigating halite deposition on well equipment such as tubing.
  • Fe-mTa is known for use as anti-caking agent for particulate NaCl, in particular in connection with membrane chlorine electrolysis.
  • the substance is commercially available from AkzoNobel.
  • the substance is also used as food additive (anti caking agent in salt) with identification E 534 under Regulation (EU) No 231/2012.
  • Fe-mTa is used herein to refer also to a complexation product of a meso-tartrate and iron (III).
  • the Fe-mTA may for example be provided as a composition comprising a mixture (such as obtained by mixing) alkali metal tartrates [DL- and meso -tartrates] (in particular the sodium tartrates) with an iron(III) salt such as iron(III)chloride.
  • the meso -tartrate content is for instance at least 10 wt.% or at least 30 wt.% or at least 50 wt.% or at least or about 65 wt.% of total tartrate content.
  • Fe-mTa comprise for example at least 10 wt.% or at least 28 wt.% meso-tartrate expressed as the anion on dry basis.
  • Fe-mTa may also be identified as the iron(III) complexation product of meso- 2,3 dihydroxibutanedioc acid, optionally in a composition also comprising such complexation product for the D(+)- and L(-)-acids.
  • Meso-tartaric acid can also be identified as (2 R ,3 S )-tartaric acid.
  • Fe-mTA may be identified with CAS number 1280193-05-9.
  • the method may optionally comprise a step of preparing a composition (preferably suitable for introduction into a gas well), preferably using a Fe-mTa stock solution (or masterbatch), for instance a solution with a pH 3.5-3.9, and/or e.g. with at least 10 wt.% or at least 20 wt.% or at least 30 wt.% of the iron(III) complexation product.
  • a surfactant e.g.
  • An aqueous solution as introduced into a wellbore may contain for example at least 1.0 ppm, or at least 10 ppm, or at least 100 ppm (all by weight) or at least 0.10 wt.%, or for example at least 1.0 ⁇ M or at least 10 ⁇ M or at least 100 ⁇ M or at least 1.0 mM of Fe-mTa on the basis of iron(III) complexation product, preferably on the basis of the meso-form, for example 5 to 500 or 10 to 200 ppm by weight.
  • the solution is for instance prepared from meso-tartaric acid monodydrate.
  • Fe-mTa the active species of Fe-mTa was identified in that document as a binuclear iron (III) complex with two bridging meso -tartrate ligands, wherein a water molecule is desorbed from the Fe-mTa complex.
  • the present application discloses use of a scaling inhibitor for inhibiting and/or mitigating halite deposition in subterranean systems, e.g. hydrocarbon wells, in particular for halite deposition in the near-wellbore region of gas wells, wherein the inhibitor is for instance a composition comprising a metal complex, e.g. with a dihydroxypolycarboxylic compound as ligand.
  • the metal is preferably selected from the group consisting of titanium, chromium and iron (iron (II) and/or iron (III)).
  • the complex is preferably nitrogen-free and the composition for example has a pH of 3 to 9. More broadly, the metal complex preferably has as a ligand compound an aldonic, uranic, or aldaric acid.
  • the ligand is capable of forming an adsorbed binuclear di-metal di-ligand complex on a halite crystal surface.
  • a metal complex of meso-tartaric acid is used, wherein the metal is one or more selected from the group consisting of iron, titanium and chromium.
  • mTa is the only ligand besides water.
  • the use of the composition preferably comprises a step of introducing the scaling inhibitor into the underground system, gas well.
  • An aspect of the invention is the use of a composition for mitigating halite deposition in gas wells, wherein the composition comprises ferri-meso-tartrate (Fe-mTa).
  • Fe-mTa is preferably the iron(III) complex described hereinabove.
  • Mitigating preferably includes one or more selected from inhibiting, preventing and/or reducing halite deposition, and/or mitigating the effects thereof, and/or causing the removal of the halite to be easier.
  • the use us for example for inhibiting (e.g. preventing, limiting and/or eliminating) production loss and/or clogging of pores in gas wells (at least partly) caused by halite deposition.
  • the use is for mitigating pore clogging by NaCl crystallization and precipitation in porous rock in the near-wellbore region of gas wells.
  • the rock is for example sandstone.
  • the rock (such as sandstone) for example has an open porosity of at least 10 vol% or at least 20 vol% or at least 30%, and for instance less than 50 vol% and/or for example has a unimodal pore size distribution of the pores with at least 50% or at least 90% of the pores (e.g. by weight normalized intrusion volume) of at least 20 ⁇ m, such as in the range of 20 ⁇ m to 30 ⁇ m, for example as measured by Mercury Intrusion Porosimetry, for instance the percentage based on weight normalized intrusion volume.
  • the gas well may comprise a downstream processing unit, for instance dehydration, especially glycol dehydration.
  • dehydration e.g. glycol dehydration
  • thermal dehydration is used for regeneration as referenced hereinabove, usually with a glycol reboiler and stripper wherein said stripper and/or reboiler is operated at a temperature of for instance of at least 150 °C, such as at about 200 ° C, or of at least 200 °C.
  • This exemplifies a downstream processing step with a temperature of at least 150 °C or at least 200 °C.
  • Any compounds used for scale prevention or halite mitigation are desirably not be liable to decomposition or reaction into harmful or toxic compounds at such high temperatures or any other downstream processing step.
  • Fe-mTa has the advantage that the presence of traces of Fe-mTa in the glycol which is regenerated, poses no or less environmental and/or health concerns, especially in connection with the thermal dehydration of glycol with a glycol reboiler and stripper, wherein said stripper and/or reboiler is operated at a temperature of for instance of at least 150 °C, such as at about 200 ° C, or of at least 200 °C.
  • the composition comprising Fe-mTa is an aqueous solution and is optionally used at (and has) a pH of 7 or lower, such as in the range of from 2 to 6, optionally at a pH of from 3 to 5, such as about 4.5.
  • a gas well may be flushed by introducing an aqueous flushing stream comprising Fe-mTa and having such pH into the well.
  • An acidic pH in these ranges may be beneficial for the effectiveness of Fe-mTa, e.g. by avoiding formation of iron hydroxide such may occur in alkaline rock.
  • Fe-mTa is used in view of at least its effect of causing the crystallization of NaCl to yield dendritic crystals, in particular in porous rocks. This can be contrasted with the normal cubic crystals of halite. The dendritic crystals may tend to grow out of the pores.
  • the halite deposits in the presence of Fe-mTa e.g. dendritic crystalline halite
  • Fe-mTa is preferably used for inhibiting pore clogging due to NaCl crystallization in gas wells, especially against pore clogging in porous rock in or associated with gas wells, such as the near-wellbore region. Any porous rock having fluid connection with a production well or injection well may for example be treated.
  • the use provides for reduced pore clogging and/or mitigating the effects thereof, and/or for more effective removal of clogs by flushing with water.
  • the use of Fe-mTa may provide for less down time (less frequent intervention) and shorter downtime.
  • the less or different halite deposition in particular dendritic crystals may also allow for higher permeability of the near wellbore region.
  • the invention also pertains to a method comprising introducing a composition comprising ferri-meso-tartrate (Fe-mTa) into the hydrocarbon well (such as an oil well or gas well).
  • the method is preferably for maintaining and/or operating a hydrocarbon well, more preferably a gas well.
  • the composition is provided into the near-wellbore region of the gas well, and more preferably into porous rock.
  • the well is at risk of or has clogging by halite deposition, or has had such clogging at least once.
  • composition as introduced into the well system generally comprises water and typically is an aqueous stream which comprises Fe-mTa and optionally a surfactant.
  • the composition is for example introduced regularly, such as at intervals, or continuously. Continuously introducing the composition can be carried out using for instance string (small-diameter tubing), for instance through the production tubing. Use of continuously introduced Fe-mTa may provide for more efficient halite deposition prevention, improved permeability and production rates, and/or a decrease of the size of the continuously introduced stream.
  • the composition may also be used as additive for conventional well flushing and well intervention methods.
  • the composition is for instance introduced into a well (e.g. wellbore) daily or more or less frequently, such as on average each every 10 to 1000 hours, or each every 24 to 120 hours.
  • a time period for shutting in the composition comprising Fe-mTa is for example in the range of about 0.5 to about 24 hours.
  • This method may involve providing Fe-mTa and shutting-in the well for a period of time sufficient to at least initiate adsorption of the Fe-mTa onto the pore walls (including NaCl crystals and/or rock matrix) of porous rock, such as in the near-wellbore region, and/or adsorption onto the wellbore (such as to tubing and equipment).
  • the composition can be introduced by flushing with fresh water, e.g. as additive of a flushing liquid.
  • the composition is for instance provided to at least 50 m or at least 100 m or at least 500 m below the datum (e.g. below the wellhead).
  • the method for example comprises pumping the composition, or a stream comprising the composition, from the surface into the well.
  • an aqueous salt solution is contacted with Fe-mTa and then reinjected into the reservoir of the gas well.
  • the method may be combined with other well treatment methods, e.g. for mitigating other kinds of scale, and these methods are optionally carried out at least partially simultaneously, such as by flushing with a liquid comprising Fe-mTa and other additives, and/or prior and/or subsequent flushing with other compounds.
  • the method may provide for mitigating halite deposition in gas wells and/or for other effects as described herein for the disclosed use.
  • the disclosed uses are for example carried out by the described methods.
  • a masterbatch composition preferably comprises Fe-mTa in an amount of 0.10 wt.% or at least 1.0 wt.% or at least 5 wt.% or at least 10 wt.% or at least 20 wt.% or at least 30 wt.%, and preferably a surfactant (e.g.
  • anionic, cationic, zwitterionic, and/or non-ionic surfactant such as in an amount of at least 0.1 wt.% or at least 1.0 wt.% or at least 5.0 wt.%, wherein the master batch preferably comprises water as liquid medium, and for example has a pH lower than 6, lower than 5, or lower than 4. All amounts for the masterbatch are based on total master batch composition.
  • an aspect of the invention pertains to a method comprising introducing a composition comprising ferri-meso-tartrate (Fe-mTa) into a subterranean (underground) system which system is liable to halite deposition, wherein the subterranean system preferably comprises at least one borehole, wellbore, one or more pumps, and/or porous rock, and wherein preferably the subterranean system is configured for flow of fluids into and/ or from the system.
  • the system is preferably capable of flow of fluids between a depth and the datum (surface), wherein the fluid is provided into or from a tube at the surface.
  • the system is preferably liable for, or has, or has had, clogging by halite deposition.
  • the use is for mitigating halite deposition in a subterranean gas injection well, e.g. a CO 2 storage site.
  • the method allows for mitigating halite deposition in such system, in particular for mitigating halite deposition in porous rock. Oil and gas wells are examples of such system.
  • the method is used for subterranean systems used as CO 2 storage site.
  • Halite deposition may also be a problem for CO 2 storage in reservoirs, for instance for methods comprising CO 2 injection in for example porous rocks such saline aquifers and depleted hydrocarbon wells.
  • the Fe-mTA can also be used for mitigating CO 2 injection impairment due to halite precipitation.
  • These methods generally comprise injecting and/or pumping a composition comprising Fe-mTa into the subterranean system, e.g. injecting the composition into a subterranean CO 2 storage site through a bore hole from the earth surface.
  • the invention also pertains to a method of making a Fe-mTa solution comprising dissolving meso-tartaric acid monohydrate and FeCl 3 • 6H 2 O in water, and adjusting the pH to 4-5 e.g. about 4.5 by adding a base, for instance NaOH; followed by stirring (further preferably according to Example 1); and also pertains to the clear solution obtained thereby, and to use thereof as described.
  • a base for instance NaOH
  • a solution of meso-tartaric acid was prepared as follows. A solution of 0.54 g of FeCl 3 • 6H 2 O and 0.34 g meso-tartaric acid monohydrate (C 4 H 6 O 6 • H 2 O) in 100 ml demineralized water was prepared. The pH of the solution was corrected to about 4.5 using a solution of NaOH. The solution was stirred for few hours, until the colour changed from orange and turbid to greenish and clear. A NaCl solution was prepared with 30 g NaCl and 100 ml demineralized water. The pH of the solution was corrected to about 4.5 by the use of HCl solution. 10 ml of the inhibitor solution was then added to 100 ml salt solution.
  • the Na-Fe-cyanide solution was prepared by adding 0.048g Na 4 Fe(CN) 6 to 100 ml demineralized water; followed by adding 30 g NaCl to the solution
  • Coarse porous sandstone was used having open porosity of about 33 vol% and unimodal pore size distribution the pores with most pores in the range of 20 to 30 ⁇ m, measured by Mercury Intrusion Porosimetry.

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  • Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Inorganic Chemistry (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Gas Separation By Absorption (AREA)
EP16190645.8A 2016-09-26 2016-09-26 Unterirdische halitabschwächung Withdrawn EP3299436A1 (de)

Priority Applications (4)

Application Number Priority Date Filing Date Title
EP16190645.8A EP3299436A1 (de) 2016-09-26 2016-09-26 Unterirdische halitabschwächung
EP17785042.7A EP3516008A1 (de) 2016-09-26 2017-09-26 Unterirdische halitabschwächung
PCT/NL2017/050641 WO2018056826A1 (en) 2016-09-26 2017-09-26 Underground halite mitigation
US16/336,375 US20190218447A1 (en) 2016-09-26 2017-09-26 Underground halite mitigation

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP16190645.8A EP3299436A1 (de) 2016-09-26 2016-09-26 Unterirdische halitabschwächung

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EP3299436A1 true EP3299436A1 (de) 2018-03-28

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EP17785042.7A Withdrawn EP3516008A1 (de) 2016-09-26 2017-09-26 Unterirdische halitabschwächung

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BR112021003504A2 (pt) * 2018-08-30 2021-05-18 Kemira Oyj métodos e composições para tratamento de halita

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0976911A1 (de) 1998-07-27 2000-02-02 Champion Technologies, Inc. Ablagerungshemmstoffe
WO2000059828A1 (en) 1999-04-02 2000-10-12 Akzo Nobel N.V. Non-caking sodium chloride crystals, a process to make them, and their use in an electrolysis process
WO2010139587A1 (en) 2009-06-02 2010-12-09 Akzo Nobel Chemicals International B.V. Non-caking salt composition, preparation process and use thereof
EP2371923A1 (de) * 2010-04-01 2011-10-05 Clariant International Ltd. Kalkhemmer
EP2597126A2 (de) 2007-10-15 2013-05-29 M-i Swaco Norge As Verfahren zum Hemmen einer Salzausfällung aus wässrigen Strömungen

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0976911A1 (de) 1998-07-27 2000-02-02 Champion Technologies, Inc. Ablagerungshemmstoffe
WO2000059828A1 (en) 1999-04-02 2000-10-12 Akzo Nobel N.V. Non-caking sodium chloride crystals, a process to make them, and their use in an electrolysis process
EP2597126A2 (de) 2007-10-15 2013-05-29 M-i Swaco Norge As Verfahren zum Hemmen einer Salzausfällung aus wässrigen Strömungen
WO2010139587A1 (en) 2009-06-02 2010-12-09 Akzo Nobel Chemicals International B.V. Non-caking salt composition, preparation process and use thereof
EP2371923A1 (de) * 2010-04-01 2011-10-05 Clariant International Ltd. Kalkhemmer

Non-Patent Citations (6)

* Cited by examiner, † Cited by third party
Title
BELLARBY, WELL COMPLETION DESIGN, 2009, pages 396
CHEN ET AL., SPE 121458
DOUG MAXWELL ET AL: "SPE-169764-MS Concept, Design and Implementation of a Halite Scale Mitigation Completion in a Gas Well", SPE INTERNATIONAL OILFIELD SCALE CONFERENCE AND EXHIBITION, 15 May 2014 (2014-05-15), XP055334009 *
JONATHAN J WYLDE ET AL: "SPE 164081 Halite Scale Formation Mechanisms, Removal and Control: A Global Overview of Mechanical, Process and Chemical Strategies", SPE INTERNATIONAL SYMPOSIUM ON OILFIELD CHEMISTRY, 8 April 2013 (2013-04-08), XP055334006 *
KIMBERLEY HO ET AL: "SPE-169803-MS Development of Novel Test Methodology to Understand the Mechanisms of Halite Inhibition and Environmentally Acceptable Halite Scale Inhibitors for High Temperature Application", SPE INTERNATIONAL SYMPOSIUM ON OILFIELD CHEMISTRY, 14 May 2014 (2014-05-14), pages 14 - 15, XP055334015 *
TORE TJOMSLAND ET AL.: "Halite Deposition - Thermodynamic Oversaturation and Chemical Qualification", OIL FIELD CHEMISTRY SYMPOSIUM, 13 March 2016 (2016-03-13)

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EP3516008A1 (de) 2019-07-31
WO2018056826A1 (en) 2018-03-29

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